Power cogeneration system and apparatus means for improved high thermal efficiencies and ultra-low emissions

ABSTRACT

A power cogeneration system employing a partially-open gaseous fluid cycle method and apparatus devices for oxy-fuel combustion conversion of a given hydrocarbon composition fuel&#39;s heat-value energy into mechanical or electrical power energy, and transferred useful heat energy, with accompanying large reductions of consumed fuel and undesirable exhaust emissions.

BACKGROUND OF THE INVENTION

To achieve a goal of significantly reducing a power cogenerationsystem's emission mass flow rate of the “greenhouse gas” (carbondioxide) by a given percentage amount, it is necessary to proportionallyincrease the thermal efficiency of a power unit apparatus' conversion offuel energy to developed mechanical power and useful applied residualthermal energy which therein proportionally reduces the amount ofcombusted hydrocarbon fuel required to provide the described energyconversion.

It has been well known and practiced for decades that higher humidityair and injected water or steam commingled with conventional aircombustion gases increases combustion flame speeds and fuel combustionthermal efficiencies within gas turbine type engines, reciprocating typeengines, and other fuel combustion burner apparatus using air/fuelcombustion. It has also been well known and practiced that partiallyre-circulating combustion flue stack gases containing carbon dioxide(CO.sub.2) back into a combustion chamber results in a reduced level ofnitrogen oxides (NO.sub.x) within the fuel combustion exhaust gases. Dueto the high temperatures and speed of completed fuel combustion, thescientific community has been unable to reach a consensus as toprecisely what series of altered chemical reactions occur when watervapor and/or carbon dioxide is introduced into an engine's fuelcombustion chamber assembly or subassembly device.

Oxy-fuel combustion burners have been employed for many years in thesteel and glass making industries to furnish desired 3000+ degreeFahrenheit combustion gas temperatures into furnaces to avoid theproduction of high (NO.sub.x) emissions, but at the expense of highcarbon monoxide (CO) emissions. Both the present air separation artmethods' high production energy costs of producing acceptable combustiongrade oxygen, and the lack of devised combustion system methods tocontrol preset desired oxy-fuel combustion burner or combustion chamberassembly or subassembly uniform maximum temperatures, have collectivelycurtailed oxy-fuel combustion applications within present fuel thermalenergy to power energy conversion facilities.

Conventional gas turbine engines or reciprocating engines must bede-rated from their standard ISO horsepower or kW ratings at ambienttemperatures exceeding 59° F., and/or at operating site altitudes abovesea level. Thus, during summer's peak power demand periods, when theambient temperature can increase to 95° F. or greater, up to 20% to 25%horsepower derations of a conventional gas turbine's ISO engine ratingcan occur. It is obviously desirable that a power turbineengine/generator unit apparatus within a cogeneration system not besusceptible to such combined on-site ambient temperature and altitudederations when peak power demands occur, or at any other time or sitelocation.

The current and future projected increasing costs of purchased utilityelectric power and natural gas (or liquid hydrocarbon fuel) and theaccepted projected future trend in the future of “distributed power”and/or power cogeneration facilities, coupled with present and futureenvironmental constraints on fuel combustion exhaust emissions, willmake it commercially mandatory that such “distributed power” and/orpower cogeneration facilities have the combined attributes (at theminimum) of combined ultra-low NO.sub.x and CO exhaust emissions andsubstantially higher thermal efficiencies than offered by current artpower cogeneration methods. It can be expected that the number of newturbine engine powered ‘cogeneration facilities in the world will besignificantly greater than the number of turbine engine powered‘combined-cycle’ facilities that are devoted purely to the production ofelectric power. The referenced ‘cogeneration facilities’ are not new inconcept. Such energy saving facilities became highly popular in the1970's (then referred to as ‘Total Energy Plants’) and were aggressivelypromoted by many natural gas utilities. Reciprocating gas engine-drivengenerator sets were the predominant producers of prime power andutilized waste heat. These ‘Total Energy Plant’ facilities efficientlyprovided electricity, hot water or steam for domestic hot water andbuilding heating requirements, and chilled water for air conditioning.‘Total Energy Plants’ were widely applied to serve hospitals,universities, large office buildings or building complexes, shoppingcenters, hotels, food processing plants, and multi-shift manufacturingand industrial facilities, etc. The 50 plus years old predecessor to the‘Total Energy Plant’ concept was the central electric power and steamplants that continue to currently serve some large eastern US cities,and more predominantly European cities and metropolitan areas.Predominantly, ‘Total Energy Plants’ and current cogeneration facilitieshave predominantly had less than 100 psig utility supplies of naturalgas available to their facilities.

It is not unusual that present art cogeneration facilities can requirefuel gas compression apparatus assemblies to supply adequate fuelpressure to the employed cogeneration method's selected power engineunits, with the said fuel gas compression consuming approximately 5% ofthe gross electric power produced by the current art power cogenerationfacility. It is therefore desirable that power cogeneration facilitiesincorporate a fuel energy to power and useful heat energy conversionmethod that requires low gas supply pressures.

When Brayton Cycle gas turbine engines operate within current artcogeneration facilities as mechanical power drive sources to electricgenerators and other mechanically driven devices, atmospheric air iscompressed and mixed with hydrocarbon gases or atomized hydrocarbonliquids for the resulting mixture's ignition and combustion atapproximately constant pressure. To produce power, the hot combustionand working motive fluid gases are expanded to near atmospheric pressureacross one or more power extraction turbine wheels, positioned inseries.

The majority of Brayton simple open-cycle aero-derivative-styleLow-NO.sub.x art gas turbine engines are predominantly presently limitedin achieving shaft output horsepower rating with 26% to 39% thermalefficiencies, whereas most simple cycle industrial-style Low-NO.sub.xart gas turbine engines are predominantly presently limited in achievingshaft output horsepower rating with 27% to 34% engine thermalefficiencies. The aero-derivative turbine engine's higher efficienciesare achieved when the gas turbine engines operate with compressor ratiosranging from 14 to 35 and predominant first stage turbine inlettemperatures ranging from 2000° to 2300° F. Typical turbochargedreciprocating-type power engine units generally have 3% to 5% higheroutput shaft thermal efficiencies than comparable power rated gasturbine power units having lesser overall life cycle operating costs.

Existing conventional applied art gas turbine and reciprocating-typeengines employ combustion chamber air/fuel combustion chemicalreactions, wherein the elements of time and high peak flame temperaturesincrease the presence of disassociation chemical reactions that producethe fugitive emissions of carbon monoxide (CO) and other chemicalreactions that produce nitrogen oxides (NO.sub.x).

The best available applied turbine engine and reciprocating-type enginelow NO.sub.x combustion technology for limiting NO.sub.x emissions,using near-stiochiometric air/fuel primary combustion reaction chemistrymeans, still results in the production of NO.sub.x and CO that are nolonger acceptable for new power or energy conversion facilities innumerous states and metropolitan environmental compliance jurisdictions.With the conventional gas turbine engine or reciprocating-type engineemployment of compressed atmospheric air as a source of oxygen (O.sub.2)which acts as a fuel combustion oxidizing reactant, the air's nitrogen(N.sub.2) content is the approximate 78% predominant mass componentwithin the cycle's working motive fluid. Due to its diatomic molecularstructure, the nitrogen molecules are capable of absorbing combustionheat only through convective heat transfer means predominantly resultingfrom their collisions with higher temperature combustion gas molecules.

Despite the very brief time it takes for conventional power engines toreach a average molecular primary flame combustion zone gas equilibriumtemperature of less than 2600° F. within its combustion chamber assemblyor subassembly, there are sufficient portions of the combustion zonegases that experience temperatures in excess of 2600° F. to 2900° F. foran ample period of time for the highly predominate nitrogen gas to enterinto chemical reactions with oxygen that produce nitrogen oxides. Thesame combined elements of time and sufficiently excessive high flametemperature permit carbon dioxide to enter into dissociation chemicalreactions that produce carbon monoxide gas.

To achieve a goal of greatly reducing a power engine unit's NO.sub.x andCO fugitive emissions, it is necessary to alter both the fuel combustionchemical reaction formula and the means by which acceptable combustionflame temperatures can be closely controlled and maintained within apower engine unit's fuel combustion assembly. Maintenance of anacceptably low selected fuel combustion peak gas temperature at alltimes and throughout all portions of within the combustion assembly,requires a change in the means by which the heat of combustion can bebetter controlled and more rapidly distributed uniformly throughout thegases contained within the fuel combustion assembly.

SUMMARY OF THE INVENTION

To achieve both power turbine engine ultra-low NO.sub.x and CO exhaustemissions (as well as reduced “greenhouse gas” carbon dioxide (CO.sub.2)emissions and enhanced simple-cycle operating thermal efficiencies, theinventor's AES gas turbine power cycle system and apparatus is describedin U.S. Pat. No. 6,532,745 dated Mar. 18, 2003. The cited invention'sfurther described partially-open gas turbine cycle contains multipleheat recovery devices for transferring waste heat to varied processgases and steam resulting in a cogeneration facility overall maximumthermal efficiency that “may approach 100%”.

The present invention describes selected process elements from the citedpartially-open AES turbine power cycle and apparatus devices that can beincorporated within a simplified and improved power cogeneration systemmethod having simplified apparatus means that can further achieveincreased power cogeneration method system and apparatus thermalefficiencies which may exceed 115%.

The addition of these selected apparatus assembly device alternatives tothe presented power cogeneration method employing a power engine unit ofthe example gas turbine engine type, as later further described andshown in FIG. 2, may increase the presented power cogeneration system'smethod overall thermal efficiency to greater than 115%.

To achieve the power cogeneration method system's ultra-low fugitiveexhaust emissions, the presented power cogeneration system methodemploys a partially-open gaseous thermal fluid energy cycle andapparatus assembly devices that provides a continuous controllable massflow rate of described recycled or “recirculated” superheatedvapor-state predominant mixture of carbon dioxide (CO.sub.2) and watervapor (H.sub.2 O), the said mixture being in identical mixture Molpercent proportions as each said molecular gas component occurs asproducts of chemical oxy-fuel combustion reactions from the gaseous orliquid hydrocarbon fuel employed.

To achieve the power cogeneration method's ability to employ gaseoushydrocarbon fuels, other than gas utility distribution quality naturalgas, the cited gaseous fuels (alternately containing toxic and/ordifficult to combust hydrocarbon molecular gases) can be rapidly carriedthrough useful fuel energy to useful heat conversion and/or completedincineration with the inventions provided system method and apparatusassembly devices that control the primary and secondary combustion zonestemperature. Whereas the invention example system method presentedrecycle exhaust gas (or alternately referred to as “recirculated cyclegas”) flow rates and temperatures are capable of producing 1800° F.tertiary zone working motive fluid gas temperatures to the example gasturbine engine's power turbine wheel sub-assembly (while maintainingherein described high thermal efficiencies and ultra-low emissions), thepreferred example 2400° F. primary and outer secondary zone combustiontemperature provides a desired 7.585 greater chemical reaction speedrate between a fuel and oxygen than that occurring at 1800° F. Asrepeatedly verified by John Zink Research in applied research, thereaction rate formula is:$\text{Reaction~~Rate~~Increase} = {(N) = \frac{\left\lbrack {\left( {2400{^\circ}\quad{F.{+ 460}}} \right) + \left( {1800{^\circ}\quad{F.{+ 460}}} \right)} \right\rbrack - 1}{.035}}$

Provided herein is a power cogeneration system method with apparatusassembly devices employing a partially-open gaseous thermal fluid energycycle for use therein of either the provided example modifiedconventional gas turbine power engine unit configurations, or usetherein of the alternative unconventional turbine power engine assemblyunit apparatus configurations that can utilize separate existing lowcost mechanical equipment apparatus assembly components and combustionchamber assembly or subassembly devices. The said assembly componentsneed not to be designed for, nor applied to, either the manufacture ofconventional engine power unit assemblies nor the said apparatus devicesand combustion chamber assemblies or subassemblies incorporation intofacility designs of current technology engine powered cogenerationfacilities (or combined-cycle facilities). The cited combustion chamberassemblies or subassemblies devices are those wherein fuel combustionoccurs at pressures greater than 1.5 bar absolute.

The invention's combined employed cited power cogeneration method andapparatus, a partially-open gaseous thermal fluid energy cycle, and thealternative added incorporation of an oxy-fuel burner apparatus (havinga fuel combustion pressure of less than 1.5 bar absolute) into thepresent invention therein provides for a commonly ‘shared non-air’working motive fluid means that is essential to the 95% to 100%reduction of NO.sub.x, and CO mass flow emissions from those ofconventional Low-NO.sub.x designed gas turbine and reciprocating enginesand/or other conventional fuel combustion apparatus devices that can beapplied within existing art power cogeneration methods and employedapparatus devices.

It is an objective of the present invention's improved powercogeneration method system and apparatus means to provide a newbenchmark standard for Best Available Technology (B.A.T.) in achievingcombined highest thermal efficiencies, lowest emissions, and lowestauxiliary facility operating power consumptions within a overalloperating power cogeneration facility.

It is a further objective of this invention to provide the means bywhich the power cogeneration method system's production of steam or hotwater, and/or the heating of process fluids, is not limited by theamount of a power engine unit/generator or power engine unit/mechanicaldrive train's availability of waste heat that can be derived from agiven production level of electric power or mechanical horsepower.

It is a further objective of this invention to provide the means bywhich the power cogeneration method system's presented alternativeapparatus devices can comprise unconventional individual power trainunit components that can be adapted to individual unit power generatorratings of 200 kW to 30 MW+ to satisfy most cogeneration facilities'installed individual unit power rating requirements.

It is a further objective of this invention to provide the collectivemeans by which deviations from the presented invention's exampleoperating conditions can be made to best accommodate a facilitydesigner's incorporation of existing models of other facility auxiliaryequipment that can be further incorporated into a specific design ofcogeneration facility, said other auxiliary equipment comprising such ascurrently manufactured absorption chillers or mechanically-drivenrefrigeration chillers that have been conventionally or similarlyapplied in related waste heat recovery power facilities for over 30years.

It is a further objective of the present invention's cogeneration methodsystem and apparatus devices to accomplish both a highly acceleratedoxy-fuel combustion process and the added capabilities to separatelycontrol both a preset maximum primary combustion zone temperature andthe tertiary zone exhaust gases temperature supplied to the example gasturbine engine unit's hot gas expansion turbine assembly. This satisfiedobjective eliminates the elements of time and high degree of temperaturethat is required for endothermic dissociation chemical reactions tooccur that produces both NO.sub.x and CO within the conventionalair-fuel combustion product gases.

It is a further objective of the present invention of improved systemmethod and apparatus devices that the example modified conventional gasturbine power engine unit assembly or alternative unconventionalre-configured turbine engine train apparatus assembly can be capable ofachieving an additional 35% to 40% in method thermal efficiencies thanare available in current art B.A.T. gas turbine engine-poweredcogeneration facilities.

It is a further objective of the present invention of improved powercogeneration method and apparatus assembly devices, that the citedexample gas turbine power engine unit and apparatus assemblies ofpreferred high efficiencies can employ (but not limited to) gascompression ratios of 2.4 to 6.4 (2.1 to 6.5 Bar operating pressure).These said gas compression ratios can be compared to conventional gasturbine engines having varied employed compression ratios ofapproximately 9 to 35.

It is a further objective of the present invention of improved powercogeneration method system and apparatus assemblies that the citedcombined gaseous thermal fluid energy cycle, apparatus assemblies, andexample gas turbine power engine unit can provide the maximumcogeneration thermal efficiencies with facility fuel gas supplypressures of less 100 psig (6.9 bar).

It is a further objective of this invention to provide the meanswherein, during a steady-state power cogeneration operation, that the‘open portion’ of the cited ‘partially-open’ gaseous thermal fluidenergy cycle therein provide an approximate atmospheric-vented gas massflow that can be approximately 5 to 8% of the total working motive fluidmass flow rate as contained within the ‘closed portion’ of the citedgaseous thermal fluid energy cycle.

It is a further objective of this invention to provide the method meanswhereby all apparatus assemblies and devices can collectively includeappropriate safety sensor/transmitter and gaseous thermal fluid flowcontrol devices. The presented invention's power cogeneration systemthermal fluid cycle streams, streams of supplied fuel and predominantoxygen, and contained apparatus assembly devices can be monitored andcontrolled for safe operation during all cogeneration facilityoperations encompassing variations in electric power generation demandsand thermal fluid heat energy extraction demands from remote suppliedsteams of steam or hot water, or process fluids.

It is a further objective of this invention to provide the combinationof power cogeneration method, apparatus assembly and control devices bywhich a non-distribution quality of gaseous hydrocarbon fuel (containingtoxic and/or difficult to combust hydrocarbon molecular gases) can berapidly carried-forth through oxy-fuel combustion to a useful heatenergy conversion and/or completed incineration without emitted toxicgas emissions to atmosphere.

The following nine embodiments comprise the subject matter of thisinvention:

First Embodiment

The working motive fluid of this invention's power cogeneration methodsystem comprises a continuous superheated vapor mixture of predominantcarbon dioxide (CO.sub.2) and water vapor (H.sub.2 O) in identical Molpercent ratio proportions as the molecular combustion product componentsMol percent ratio proportions are produced from the combustion of thegaseous or liquid hydrocarbon employed fuel.

Within the predominately-closed portion of the presented invention'scited power cogeneration method's partially-open gaseous thermal fluidenergy cycle, the re-circulated power engine unit exhaust gas is routedfrom an exhaust gas distribution manifold (the exhaust gas having asmall degree of superheat temperature and positive gage pressure supply)into the inlet of the recycle gas compressor. The exhaust gas recyclecompression function can be performed by a more typical axial compressorsection used for air compression within a conventional gas turbine powerengine unit, or it may be a separately power driver device-drivencompressor of the axial, centrifugal, or rotating positive displacementtype. Either described type of compression can incorporate means of flowcontrol available within the compressor or by its driver's varied speed,with flow changes being initiated by a power cogeneration PLC typecontrol panel containing programmable logic microprocessors.

The cited type of compressor can increase the example gas turbine powerengine unit's recycled or recirculated exhaust's absolute pressure by aratio range of only 2.4 to 6.4 to achieve a relatively high example gasturbine power engine unit “stand-alone” simple-cycle thermal efficiency,but the in the case of the said gas turbine power engine unit'sincorporation into the invention's cited combined power cogenerationmethod and apparatus assembly devices, the gas turbine power engine unitis not limited to operations within these said ratios.

As shown in Table 1, between the example gas turbine engine unit's fuelcombustion pressures of 45 psia and 75 psia, the cited gas turbine powerengine unit's “stand-alone” simple-cycle thermal efficiencies can rangebetween 35.16% and 43.24%. Between 75 psia and 90 psia oxy-fuelcombustion burner assembly pressures (with the common individual recyclecompressor and hot gas expander power turbine assembly efficiencies of84%, and a stage 1 turbine inlet temperature of 1800° F.), the cited gasturbine engine power unit “stand-alone” (simple-cycle) efficiencies canbegin to decline. TABLE 1 Combustion Gas Turbine Gas Turbine Gas TurbineThermal Operating Gas Inlet Exhaust Net Output Gas Turbine FuelEfficiency Pressure Temperature Temperature Horsepower Rate Btu/HP-Hr.%* 45 psia 1800° F. 1471° F. 2859 7237 35.16 60 psia 1800° F. 1391° F.3458 5983 42.54 75 psia 1800° F. 1331° F. 3515 5885 43.24 90 psia 1800°F. 1284° F. 3406 6075 41.89*With a 1 Mol/minute methane gas fuel rate

The re-cycled (or recirculated) and re-pressurized turbine exhaust gas(hereafter can be referred to as “either recycle gas, or re-pressurizedrecycle gas” within the cited power cogeneration method's partially-opengaseous thermal fluid energy cycle) is discharged from the recycle gascompressor at an increased temperature and pressure through a conduitmanifold containing both a side-branch connection and first and secondparallel conduit end-branches flow-controlled streams. The conduitmanifold side-branch supplied controlled low mass flow stream of recyclegas can be reduced in temperature within an air-cooled exchanger priorto the stream flow's entry into one or more preferred partial pre-mixsubassembly contained within each oxy-fuel combustion chamber assemblyor subassembly. Within each referred partial pre-mix assembly, thereduced temperature recycle gas stream can be homogenously pre-mixblended with the supply stream of predominant oxygen that is also isalso supplied to the preferred partial pre-mix subassembly and/orpre-mix blended with the supply stream of fuel.

The fore-cited first and second parallel conduit end-branchesflow-controlled streams having end-connectivity respectively to theinlets of first and second headers of the power turbine exhaust gaswaste heat recovery unit (WHRU) exchanger of counter-current flow gas togas heat exchange design. A predominate flow-controlled portion of theexample gas turbine power engine unit developed high temperature exhaustis flow-directed through the cited WHRU exchanger for its heat transferinto the recycle gas stream that thereafter is downstream re-admittedinto the oxy-fuel fired combustion chamber assembly.

This example gas turbine power engine unit exhaust gas WHRU exchangercan be capable, with the particular example of a methane fuel combustionchamber pressure of 60 psi absolute and 1800° F. first stage hot gasexpansion power turbine inlet temperature, of raising the temperature ofthe re-pressurized recycle gas within the turbine exhaust gas WHRUexchanger to an approximate maximum 1350° F. temperature. With theseoperating conditions and assumed individual compressor and hot gasexpansion turbine efficiencies of 84%, the example gas turbine engineunit “stand-alone” simple-cycle thermal efficiency of 42.5% can beachieved.

Thereafter, the 1350° F. highly superheated and re-pressurized recyclegas individual streams (and/or higher temperature method cycle fluidstreams) can hereafter be referred to as “working motive fluid” gasstreams. The first controlled stream of working motive fluid can berouted and separately flow-divided as required to the internal tertiaryblending zone contained within each of one or more oxy-fuel combustionchamber assembly or subassembly that can be conventionally positionedradially about the centerline axis of the example gas turbine powerengine unit. The second controlled stream can be separately flow-dividedas required for passage into one or more preferred partial premixsub-assemblies contained within one or more oxy-fuel combustion chamberassembly.

Within the presented power cogeneration system method, a lesser flowcontrolled portion of the total example gas turbine power engine unit'sdischarged exhaust flows through the waste heat recovery steam generator(WHRSG) exchanger or waste heat recovery process fluid (WHRPF)exchanger.

Second Embodiment

From the First Embodiment's “the re-circulated power engine unit exhaustgas is routed from a exhaust gas distribution manifold (the exhaust gashaving a small degree of superheat temperature and positive gagepressure supply) into the inlet of the recycle gas compressor”, the saidre-circulated power engine unit exhaust gas within the exhaustdistribution manifold comprises the discharge exhaust gas from a secondWHRSG or WHRPF exchanger upstream that is inlet-connected to are-circulated exhaust gas manifold that conveys the combined example gasturbine power engine unit's reduced temperature exhaust gasesoriginating from both the WHRU exchanger and the firstparallel-positioned WHRSG or WHRPF exchanger into which the totalexample gas turbine power engine unit's high temperature exhaust isfirst inlet-connected.

Either the second WHRSG or second WHRPF exchanger can perform theinitial heating of supplied streams from either a facility's steam orhot water feed circuit or a process fluid stream prior to either ofthese streams being further downstream flow-connected to thefore-described high temperature example gas turbine power engine unitexhaust gases first WHRSG exchanger or WHRPF exchanger.

Third Embodiment

From the First Embodiment cited re-circulated example turbine powerengine unit exhaust from the exhaust gas distribution manifold suppliedto the inlet of the primary recycle gas compressor, the exhaust gasdistribution manifold has a end manifold alternative system connectionpoint and two side-branch flow delivery connections. The firstside-branch conduit provides the greatly predominant flow ofre-circulated exhaust gas into the inlet of the recycle gas compressor,and the second side-branch conduit directs the controlled flow of excessof re-circulated turbine exhaust gases to atmosphere during steady-stateoperation of the presented system. This flow of excess citedre-circulated turbine exhaust gases to atmosphere constitutes the “OpenPortion” of the presented partial-open power cogeneration method system.The system steady-state condition's controlled mass flow rate, in whichthe re-circulated turbine exhaust is vented to atmosphere, is equivalentto the combined mass rates at which the fuel and the predominant oxygengas streams enter the invention's provided oxy-fuel combustion systemmethod's partially-open cycle and apparatus devices.

Fourth Embodiment

From the First Embodiment cited “The second controlled stream can beseparately flow-divided as required for passage into one or morepreferred partial pre-mix sub-assemblies contained within one or moreoxy-fuel combustion chamber assembly.”, each partial pre-mixsub-assembly having the following introduced controlled streams: fuel; apredominant oxygen stream which originates from an adjacent facilityarea containing a preferred highly electric energy efficient modular airseparation system; First Embodiment described air-cooled recycle gas;and second stream of working motive fluid. These individual flowcontrolled conduit streams are collectively admitted through theirrespective pre-mixer inlet conduit means for preferred selectivepre-mixing and homogeneous blending at points of admittance into theprimary combustion flame zone and outer secondary zone within eachoxy-fuel combustion chamber assembly.

To establish primary combustion temperatures that do not exceed theexample preferred maximum 2400 F, one of several possible acceptabledesigns of pre-mix sub-assembly can be one of wherein the oxy-fuelcombustion chamber assembly (a specific method or design of which is notwithin the scope of the presented invention) can incorporate both aprimary oxy-fuel combustion flame zone and a secondary outer zonewherein a predominant portion of the fore-described second stream ofworking motive fluid is introduced into a outermost flow annulus areasurrounding the homogeneous mixture admitted from each pre-mixsub-assembly into the said primary combustion flame zone for ignition.The secondary outer zone introduced working motive fluid can therebyprovide a closely positioned rapid heat-absorbing greater mass shroudingmeans around each primary combustion flame zone developed within theoxy-fuel combustion chamber assembly. This flame shrouding means canenable the radiant heat energy emanating from the lesser mass binary gasmolecules within the combustion flame to be rapidly distributed to andabsorbed uniformly by the described shroud's contained greater mass ofidentical binary gaseous molecules at the speed of light rate of 186,000miles per second. The resulting equilibrium temperature within eachoxy-fuel combustion chamber assembly's primary combustion flame zone andsecondary zone, based on the controlled flow rate of the second streamof working motive fluid into the oxy-fuel combustion chamber assembly,can be established as being equal to a preset desired example of amaximum 2400° F. or other desired preset temperature that issubstantially less than the temperature at which NO,sub.x and CO can beformed during endothermic disassociation chemical reactions. The examplemaximum 2400° F. merely represents a conservative maximum temperature tototally avoid the slightest potential of any combined production ofextremely small trace amounts of NO.sub.x and companion larger amountsof CO.

Fifth Embodiment

From the First Embodiment cited “The first controlled stream of workingmotive fluid can be routed and separately flow-divided as required tothe internal tertiary blending zone contained within each of one or moreoxy-fuel combustion chamber assembly or subassembly that can beconventionally positioned radially about the centerline axis of theexample gas turbine power engine unit”, the first controlled stream ofworking motive fluid to the tertiary blending zone flow can beintroduced into an oxy-fuel combustion chamber assembly's inner annulusarea between the chamber assembly's outer casing and an inner linersurrounding each primary oxy-fuel combustion flame zone and outersecondary zone, followed by its flow emanation into the chamberassembly's downstream-positioned tertiary blending zone chamber areathrough openings in the said inner liner. This tertiary zone introducedmass flow of superheated working motive fluid (of example 1350° F.temperature) blends with the example maximum 2400° F. equilibriumtemperature combined gases emanating from the chamber assembly's primaryoxy-fuel combustion flame zone and its outer secondary zone to therebyproduce a resultant example 1800° F. final oxy-fuel combustion chamberassembly exhaust equilibrium temperature to the hot gas expansionturbine assembly. The equilibrium temperature of the final oxy-fuelcombustion chamber assembly exhaust gases is not limited to 1800° F.,and can be controlled by the introduced tertiary working motive fluidmass flow rate and/or fuel mass flow rate to establish any other higheror lower selected operating temperature. The example 1800° F.temperature can be chosen to coincide with 10 year old proven powerturbine blade metallurgy technology for continuous operation.

Within the one or more hot gas expansion turbine stages, the oxy-fuelcombustion chamber assembly's pressurized and highly superheated gasesare expanded to create useful work in the conventional form of bothturbine power engine unit output shaft horsepower and (in the case of aconventional modified gas turbine power engine unit configuration)internal horsepower to additionally direct-drive the recycle gascompressor. In a conventional 2-shaft style of gas turbine engineconfiguration, the recycle gas compressor can be shaft-connected to thehigh-pressure stage section of the power turbine assembly, and the lowpressure section of the power turbine engine assembly with connectedoutput shaft therein provides the turbine power assembly output power todriven equipment. The expanded exhaust gases exit the power turbineassembly at a low positive gage pressure and are further conveyedthrough conduit means to the fore-described WHRU exchanger and adjacentparallel-position WHRSG or WHRPF exchanger as further described laterand shown in FIG. 1.

Sixth Embodiment

In the Fifth Embodiment description “In a conventional 2-shaft style ofgas turbine engine configuration, the recycle gas compressor can beshaft-connected to the high-pressure stage section of the power turbineassembly, and the low pressure section of the power turbine engineassembly with connected output shaft therein provides the turbine powerassembly output power to driven equipment.”, the presented inventionprovides an alternative system method and apparatus devices by which anunconventional turbine power engine unit train (comprising individualseparate compressor unit assembly, oxy-fuel combustion chamber assembly,and hot gas expansion turbine assembly unit with mechanical shaftoutput) can be configured to produce mechanical or electrical powerwithin a cogeneration method system as described later and shown in FIG.2.

The invention's alternative recycle gas compressor can be a separatelymotor-driven or stream turbine-driven compressor of centrifugal or axialtype therein comprising one or more stages of compression as required,or single rotating positive displacement type compressor for the systemapplied operating conditions. The re-circulated and slightly superheatedturbine exhaust gas stream is re-introduced into the recycle gascompressor and increased in pressure and temperature as described forthe conventional gas turbine power system. This presented style ofrecycle gas compression drive train generally offers greatly improvedcapacity control and/or turn-down capabilities, but can be overall lessefficient than the conventional type gas turbine assembly'sdirect-driven axial compressor section.

As described in the Fourth and Fifth Embodiment, the oxy-fuel combustionchamber assembly configuration and functional operation remainsunchanged. Rather than the Fifth Embodiment described one or moreoxy-fuel combustion chamber assembly being conventionally positionedradially about the centerline axis of the example gas turbine engineunit, the presented invention's alternative system and apparatus meanscan further have a single oxy-fuel combustion chamber assembly that isaxially centerline-positioned and can be directed-connected to the hotgas expander power turbine as shown later in FIG. 2.

Seventh Embodiment

From the Second Embodiment's cited “the said re-circulated power engineunit exhaust gas within the exhaust distribution manifold comprises thedischarge exhaust gas from a second WHRSG or WHRPF exchanger upstreamthat is inlet-connected to a re-circulated exhaust gas manifold thatconveys the combined example gas turbine power engine unit's reducedtemperature exhaust gases originating from both the WHRU exchanger andthe first parallel-positioned WHRSG or WHRPF exchanger into which thetotal example gas turbine power engine unit's high temperature exhaustis first connected.”, the total amount of exhaust waste heat that canusefully be transferred into the said heat exchanger's supplied fluidsis limited to (or in proportion to) the amount of mechanical outputpower that is developed by the invention's power cogeneration systemmethod employed power engine unit.

The presented invention provides an alternative method system andapparatus devices by which the presented power cogeneration method'sproduction of steam or hot water (or heating of process fluids) isindependent of the amount of power engine unit developed mechanicalpower. This presented invention, with its described alternative methodsystem and apparatus devices, provides this power cogeneration methodwith added operational flexibility while further increasing the thermalefficiency of the presented invention's cogeneration method andmaintaining the same ultra-low exhaust emissions. Wherein an examplepresented given power cogeneration system facility of a given mechanicalpower output rating could fully utilize at all times a 100% or greatersteam production or process fluid heating than would be associated withthe cogeneration method system and apparatus devices shown in FIG. 1,the FIG. 2 presented alternative cogeneration system and apparatusdevices can include the presented supplementary oxy-fuel fired heatingof a selected portion of combined apparatus generated recirculatedsystem exhaust gases to achieve both the generated power and theadditional production of steam or process fluid heating. The FIG. 2described alternative method system and apparatus provides the devicemeans of achieving the presented overall cogeneration system thermalefficiencies that can significantly exceed 115% as shown later in Table5 for an example 100% increase in steam or process heating beyond theFIG. 1 system capabilities.

The presented invention's alternative method system and apparatusassembly devices includes the added conduit means for withdrawal of aportion of cited combined re-circulated exhaust gases from the ThirdEmbodiment described exhaust gas distribution manifold. The citedconduit means provides a routed supply of the re-circulated exhaustgases to the example FIG. 2 preferred two parallel auxiliary primaryrecycle blowers that are separately capacity controlled to produceslightly re-pressurized first and second conduit stream flows of exhaustrecycled gas that are connected to the alternative cogeneration system'sauxiliary oxy-fuel fired combustion burner assembly unit.

The cited oxy-fuel fired combustion burner assembly employs additionalindividual connected flow controlled streams of fuel and predominantoxygen to produce an identical composition of additional combustionexhaust gases as existing within the example gas turbine power engineunit's exhaust gases, whereby the said additional oxy-fuel firedcombustion burner assembly's exhaust gases are conduit routed into theturbine exhaust conduit branch connecting to the WHRSG exchanger orWHRPG exchanger described above in the above cited Second Embodiment.

In the case of the FIG. 1 configuration of the presented invention'spower cogeneration method system and apparatus assembly devices, anyincrease in power generation (beyond the then existing cogenerationsystem's ‘steady-state’ production condition, but not exceeding theexample presented gas turbine's power engine unit output continuousrating), can be accomplished by terminating the controlled flow ofvented excess turbine re-circulated exhaust flow to atmosphere andincreasing the fuel flow and predominant oxygen gas flow. Only uponreaching the required accumulated increased mass flow of preset hightemperature exhaust gases within the closed system, shall the presentedinvention's power cogeneration method system then be returned to itsnormal ‘steady-state’ and ‘partially-open system status’ with controlledexcess re-circulated exhaust gas vented to atmosphere.

Eighth Embodiment

From the First Embodiment cited “As shown in Table 1, between theexample gas turbine power engine unit's fuel combustion pressures of 45psia and 75 psia, the cited gas turbine power engine unit's“stand-alone” simple-cycle thermal efficiencies can range between 35.16%and 43.24%.” The invention's improved high thermal efficient powercogeneration method's presented example 60 psia oxy-fuel combustionchamber assembly therein enables a low fuel supply pressure of less than65 psi gage (5.5 Bar) to be employed.

Ninth Embodiment

From the preceding collective Embodiments' cited control of fluid streamflows, temperatures, pressures, generated power, and apparatus meansincludes valves, compressors, blowers, motors, etc., the presentedinvention's power cogeneration method system and apparatus means can beboth performance and safety monitored and controlled by a manufacturer'sPLC based control panel design that meets or exceeds the powercogeneration facility's applicable industry and governmental standardsand codes, and as is applicable to the power cogeneration method'sspecifically employed apparatus assembly devices. The operating powercogeneration method system's operating data signals can comprise, butnot limited to:

-   (a) the power cogeneration method system's apparatus connecting    conduits containing individual valve controlled gas stream's mass    flows with temperatures and pressures for a given operating    hydrocarbon fuel composition and horsepower or kilowatt output, and    effective waste heat transfer duty;-   (b) the power cogeneration method system's power engine unit exhaust    and waste heat recovery unit's fluid conditioning status and power    engine unit exhaust excess oxygen content for a given operating    hydrocarbon fuel composition;-   (c) the power cogeneration method system's power engine unit exhaust    and recycle gas compressor discharge mass flow rates through their    respective downstream waste heat recovery exchangers;-   (d) the power cogeneration method facility's auxiliary rotating    equipment's operating mass flow rates with temperatures and    pressures combined with the positioning-state of any rotating    equipment's integral capacity control apparatus;-   (e) the power cogeneration method facility's rotating equipment and    alternative blower/oxy-fuel fired combustion burner assembly safety    monitoring condition point locations as set forth by the prevailing    industry or government specifications for each type of equipment, as    well as those monitoring points whose operating condition state can    impact on the power cogeneration method apparatus assembly device's    operational on-line availability and equipment life cycle costs.

Overall System Method and Apparatus Means

Within the presented improved power cogeneration system method andapparatus assembly devices described herein, the provided systememployed oxy-fuel combustion generated working motive fluid means canprovide a 95 to 100% reduction of nitrogen oxides (NO.sub.x) that occurswithin current art Low-NO.sub.x employed type of power engine units. Thepartially-open gaseous thermal fluid energy cycle contained within thecited power cogeneration method's provides a temperature controlledoxy-fuel combustion temperature and the speed of combustion flame heattransfer that also similarly suppresses the chemical reactiondissociation formation of the fugitive emission carbon monoxide (CO)from carbon dioxide (CO.sub.2). The means of suppressing the developmentof fugitive emissions results from the following collective workingmotive fluid molecular attributes and combustion events:

-   -   (a) The working motive fluid of this invention's power        cogeneration method system and apparatus devices comprises a        continuous superheated mixture of predominant carbon dioxide        (CO.sub.2) and water vapor (H.sub.2 O) in identical Mol percent        ratio proportions as these molecular components are produced        from the combustion of a given fuel. For example, in the case of        landfill gas, the working gas fluid contains a 1:1 ratio of 2        Mol carbon dioxide to 2 Mols water vapor in identical proportion        to the products of stoichiometric oxygen combustion. The        chemical reaction equation can be described as follows:        Working Motive Fluid+1 Mol CH.sub.4+1 Mol CO.sub.2+2 Mols        O.sub.2=2 Mol CO.sub.2+2 Mol H.sub.2 O+Heat+Working Motive        Fluid.        In the example of methane gas fuels, the working fluid        composition contains a ratio of 1 Mol CO.sub.2 to 2 Mols H.sub.2        O in identical proportion to the products of 105% stoichiometric        oxygen combustion of methane fuel within the chemical reaction        equation of:        Working Motive Fluid+1 Mol CH.sub.4+2.1 Mols O.sub.2=1 Mol        CO.sub.2+2 Mols H.sub.2 O+0.1 Mol O.sub.2+Heat+Working Motive        Fluid;    -   (b) The invention's power cogeneration system's method's working        fluid provides the replacement mass flow means to conventional        open power cycles incorporating the predominant diatomic        non-emissive and non-radiant energy absorbing molecular        component nitrogen (N.sub.2) within the cited-conventional        cycles working motive fluid. The invention's replacement working        motive fluid contains both predominant water vapor (with a        binary lack of molecular symmetry) and a mass ratio of atomic        weights of (16/2)=8 and carbon dioxide with a mass ratio of        atomic weights of (32/12)=2.66, which denotes their        susceptibility to high radiant energy emissivity and absorption.        This compares to the nitrogen's mass ratio 14/14=1 which denotes        nitrogen's minimal, if any, emissive and radiant energy        absorbing abilities at any temperature;    -   (c) The presented invention's power cogeneration method's cycle        system's controlled flow of working motive fluid into the        oxy-fuel combustion chamber assembly therein provides the said        assembly's interior gaseous environment with an approximate 900%        increase of binary molecular mass means susceptible to the        fuel/oxidation exothermic chemical reactions generated        combustion heat transfer being highly accelerated at the speed        of light (186,000 miles a second). The cited highly accelerated        rate of combustion heat transfer to the highly predominant        interior binary gases within the cited combustion apparatus        assembly, provides the means by which a controlled highly        superheated temperature equilibrium state of accelerated fuel        and oxygen reaction rates is maintained without the prospect of        developing CO2 disassociation reactions that produces CO in the        presence of the highly elevated gas molecular temperatures above        2600° F. to 2900° F.;

The cited binary gases being comprised of individual binary carbondioxide and binary water vapor molecular gases whose individualmolecular mass heat energies are separately emitted or adsorbed in theirown individual and specific narrow and unique infrared spectral ranges.

The radiant heat is transferred from the cited binary carbon dioxide andbinary water vapor combustion gaseous products in their specific Mol %proportions as determined by the molecular fuel being combusted, thesaid gaseous Mol % proportions being sustained throughout the gaseousthermal fluid energy cycle, including the working motive fluid thatenters the fuel combustion chamber assembly device along with suppliedfuel and oxygen.

-   -   (d) The First Embodiment recited oxy-fuel combustion chamber        assembly pre-mix sub-assemblies provides the means for        homogeneous blending, wherein gaseous streams of working motive        fluid and an oxygen-rich stream can be further homogeneously        blended for downstream mixing and ignition with the gaseous fuel        stream. The gaseous fuel stream also comprises binary molecules        of high susceptibility to high radiant energy absorption and        emissivity, such as methane with a mass ratio of atomic weights        of (16/4)=4, ethane with a mass ratio of atomic weights of        (24/4)=6, propane with a mass ratio of atomic weights of        (36/8)=4.5, etc;    -   (e) The subsequent tertiary zone admission of a controlled-flow        of Table 1 identified 1350° F. superheated working motive fluid        into the example 2400° F. combustion chamber assembly's primary        oxy-fuel combined primary combustion flame zone and its outer        secondary zone combustion gas stream, results in the rapid        creation of the example desired equilibrium temperature of        1800° F. This rapid establishment of the preferred equilibrium        temperature is due to the 186,000 miles per second rate of        radiant heat transfer between the two streams of common        molecular constituents with common means of high radiant energy        absorption and emissivity in their respective individual        infra-red spectrum ranges.

The presented improved power cogeneration method and apparatus devicesemploy a partially-open gaseous thermal fluid energy cycle thereinincorporating an oxy-fuel fired combustion system's apparatus assemblygenerated working motive fluid gases of optimum selected operatingpressures and temperatures that can achieve 115% or greater powercogeneration facility thermal efficiencies. The means of achieving these40% to 50% increased thermal efficiencies than those thermalefficiencies provided by current art conventional cogeneration powerfacilities (thereby reducing CO.sub.2 “greenhouse mass flow emissions”by 40% to 50%), results from the following improved power generationmethod and apparatus devices, employed partially-open gaseous thermalfluid energy cycle, and the collective working fluid molecular thermalcharacteristics or attributes comprising:

-   -   (a) The oxy-fuel combustion chamber assembly's low operating        pressures reduces the work (per pound of primary recycled gas)        that is adsorbed by the employed power engine unit's compressor        apparatus assembly, the said compressor re-pressurizing the        recycled power engine unit exhaust gas stream that subsequently        becomes the downstream highly superheated working motive fluid        that is expanded through the employed power engine unit's hot        gas expansion power output assembly;    -   (b) The presented improved power cogeneration method system        working motive fluid molecular gas composition replaces air        content nitrogen that is the predominant mass flow molecular gas        component in a conventional internal combustion engine's working        motive fluid. The presented improved power cogeneration method        system working motive fluid is unique in that each highly        superheated temperature pound of fluid can adsorb or exchange        approximately 42% more heat per degree Fahrenheit change in gas        temperature than does air or nitrogen.    -   (c) In the presented example operating conditions, approximately        92% of the high temperature example gas turbine power engine        unit exhaust heat energy that is recovered from within the total        exhaust flow passing through the WHRU exchanger and first WHRSG        exchanger (or WHRPF exchanger) is transferred back into the        pressurized working motive fluid that will re-enter the oxy-fuel        combustion chamber assembly to further absorb the heat of fuel        combustion.    -   (d) Approximately 92 to 95% of the presented improved power        cogeneration method system's re-circulated exhaust downstream of        the waste heat exhaust exchangers (therein still containing a        large ‘heat sink’ quantity of energy) can approximately be        recycled within the closed portion of the improved power        cogeneration method system during steady-state operation. During        an increased energy output demand on the presented power        cogeneration method system, 100% of the presented improved        cogeneration method system's re-circulated exhaust heat capacity        downstream of the waste heat exhaust exchangers can be recycled        during its accompanying ‘total-closed’ cycle method system        operation.    -   (e) The presented improved power cogeneration method system        employed partially-open gaseous thermal fluid energy cycle, and        the described operating characteristics of the continuous and        uniform superheated gaseous heat transfer fluid, enables the        presented power cogeneration method to annually maintain a        continuous facility power output rating without any imposed site        ambient temperature derations.

With the presented example turbine power engine unit cogeneration methodsystem and apparatus assembly devices described herein, or including thepresented alternative system power cogeneration method and employedapparatus assembly devices, either a modified conventional gas turbinepower engine unit apparatus train or an unconventional turbine powerengine unit train comprised of two or more apparatus assemblies can beemployed. An alternative turbine power engine unit assembly unitapparatus configuration can utilize separate existing low costmechanical equipment components and combustion chamber and burnerassemblies which can be predominantly not designed for, nor applied to,the manufacture of conventional gas turbine power engines, nor the saidcomponents' incorporation into facility designs of current technologypower cogeneration facilities.

Within the presented power cogeneration method system and apparatusassembly devices described herein, the presented invention provides analternative improved power cogeneration method and apparatus assemblydevices by which a power cogeneration-method system's production rate ofsteam or hot water (or heating of process fluids) can be independent ofthe actual percentage of full-rated mechanical or electric power loadthat is being produced from the described power cogeneration methodsystem. The presented example alternative power cogeneration methodsystem and apparatus assembly devices is not limited in its ability tohave expanded steam or hot water or process fluid heating capacitycapabilities beyond that which is possible solely from a power engineunit's exhaust gas waste heat utilization.

Within the presented power cogeneration method system and apparatusassembly devices described herein, the apparatus assembly devices areprovided wherein all fluid streams entering the oxy-fuel combustionchamber assembly (and alternative combustion burner assembly) arecontrolled to maintain preset maximum combined primary combustion flamezone and outer secondary zone temperatures in which a non-distributionquality of gaseous hydrocarbon fuel (containing toxic and/or difficultto combust hydrocarbon molecular gases) can be rapidly carried throughthe oxy-fuel combustion method to a useful heat conversion and/orcompleted incineration without significantly altering the methodsystem's high thermal efficiencies or ultra-low emission levels.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a schematic flow diagram of the invention's improved powercogeneration method system and apparatus devices employed within apartially-open gaseous thermal fluid energy cycle therein incorporatingan example modified configuration of a conventional gas turbine powerengine unit and simplified waste heat transfer apparatus for eithersteam or hot water generation, or process fluid heating.

FIG. 2 is a schematic flow diagram of the invention's improvedcogeneration method system that includes the presented partially-opengaseous thermal fluid energy cycle of FIG. 1, and additional alternativeexample comprising a non-conventional turbine power engine unit andapparatus assembly devices including an alternate separate motor orsteam turbine driven recycle or recirculated exhaust gas compressor, anoxy-fuel combustion chamber assembly series-connected to a hot gasexpander turbine device, and an alternative supplementaryblower/oxy-fuel fired combustion burner assembly that can sustain ratedsteam or hot water production or heating of process fluids irregardlessof the said example non-conventional turbine power engine unit's outputof mechanical or electric power.

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT

Referring now more particularly to FIG. 1, an example modifiedconventional gas turbine engine power unit's exhaust recycle gascompressor section 1 comprises two or more recycle exhaust gascompression stages, positioned in series, with a final stage of radiallydirected discharge flow of compressed or re-pressurized recycle exhaustgas. In the case of a two-shaft turbine engine, the power to drive therecycle gas compressor section 1 is transmitted by shaft 2, on which oneor more high-pressure power extraction turbine stages are mounted withinthe combustion hot gas expansion power turbine assembly 3. The secondshaft, designed for mechanical equipment or generator driveapplications, has one or more low-pressure hot gas expansion powerstages mounted on power output shaft 4, with coupling means for powertransmission to rotate the driven equipment.

The invention's improved power cogeneration method adaptation tomodified conventional gas turbine engine driven mechanical equipment mayor may not require the addition of a gearbox or variable speed coupling5 to adapt the speed of the hot gas expansion power turbine assembly 3to the speed required by a generator or other driven equipment (notshown). The rotating driven equipment may have its required powertransmitted through a shaft and coupling device 6. The shaft andcoupling means device 6 can transmit power to a generator 7, whereinelectric power is produced and transmitted through conduit means 8 to acontrol room module 9. Control room module 9 therein can contain theturbine power engine unit's PLC control panel, electrical switchgear,and motor control center, whereby electric power production iscontrolled and distributed to the power cogeneration facility'selectrical grid and/or connected electric utility electrical grid. Theshaft and coupling device 6 may alternately transmit power to otherrotating pumps or compressors (not shown) in lieu of generator 7.

Within the presented invention's improved power cogeneration systemmethod, including a partially-open gaseous thermal fluid energy cycleand apparatus devices, the slightly superheated example turbine powerengine unit's re-circulated exhaust gas flows from the exhaust gasdistribution manifold 10 (having end-connection 62 that is blind-flangedclosed in this FIG. 1) through said manifold side-branch connectedexhaust recycle gas conduit means 11 that is end-connected to the inletof the recycle gas compressor section 1. The higher-pressure andhigher-temperature compressed gas discharged from the recycle gascompressor section 1 (hereafter referred to as “recycle gas, orre-pressurized recycle gas”) is routed through conduit manifold 12containing two parallel conduit end-branches 13 and 14 respectively,either one or both said conduit branch therein containing a gas massflow sensor means and a flow control (or flow proportioning) dampervalve 15.

The twin parallel conduit end-branches 13 and 14 respectively conveyfirst and second primary re-pressurized recycle gas streams withrespective end connections to parallel inlet headers 16 and 17 locatedon the section 18 of the example turbine power engine unit's exhaust gaswaste heat recovery unit (WHRU) exchanger. The said first and secondstreams of re-pressurized recycle gas is discharged from section 18 ofthe cited turbine power engine unit's WHRU exchanger through outletheaders 20 and 19 respectively at highly increased superheatedtemperatures (with the highly superheated recycle gas hereinafterreferred to as a “working motive fluid”) with flows through conduits 21and 22 respectively.

The re-pressurized recycle gas additionally can be routed at low gasflow levels from conduit manifold means 12 through a side-branchconnected conduit means 23 containing motor driven air-cooler 24 andflow control valve 25 for subsequent downstream conduit end-connectionto one or more partial premix sub-assemblies 27 that can be containedwithin one or more oxy-fuel combustion chamber assembly 26, the saidassembly may therein preferably be conventionally positioned radiallyabout the centerline axis of the cited turbine power engine unitassembly.

Conduit 22 conveys the second controlled stream of working motive fluidto the internal primary combustion zone 28 contained within eachoxy-fuel combustion chamber assembly 26. Conduit 21 conveys the firstcontrolled stream of working motive fluid to the internal tertiaryblending zone 29 contained within each oxy-fuel combustion chamberassembly 26 that can be positioned radially about the centerline axis ofthe turbine assembly. The combined streams of working motive fluidcomposition gases exiting tertiary blending zone 29 can be routedthrough conduit flow means 30 having end connection to the inlet of thehot gas expansion power turbine assembly 3.

Alternately the conduit 21 can convey the first controlled stream ofworking motive fluid to a common single tertiary blending zone thatreceives primary combustion zone working fluid composition gases fromtwo or more oxy-fuel combustion chamber assembly 26 that is positionedimmediately upstream of the described alternate single common (notshown) tertiary blending zone. The combined streams of working motivefluid composition gases exiting the common tertiary blending zone (notshown) are routed through conduit 30 having end connection to the inletof the hot gas expansion power turbine assembly 3.

A pressurized stream of presented example methane fuel gas (or alternateacceptable liquid hydrocarbon fuel) is supplied from source 31 intoconduit 32 that therein can contain sensor-transmitter devices fortemperature, pressure, mass flow, and a fuel flow control valve device33, with said conduit having end-connectivity to either one or morepreferred downstream partial pre-mix subassembly 27 contained withinoxy-fuel fired combustion chamber assembly 26.

A controlled pressurized stream of predominant oxygen gas is suppliedfrom a facility remote source 34 into conduit 35 that may containsensor-transmitter devices for oxygen %, temperature, pressure, massflow, and a flow control valve device 36, with said conduit havingend-connectivity to either one or more preferred partial pre-mixsubassembly 27 contained within oxy-fuel combustion chamber assembly 26.

Within the partial pre-mix subassembly 27, the said identified conduits23, 32, and 35 respectively supplied controlled stream flows ofre-pressurized recycle gas, fuel, and predominant oxygen are thereinpartially blended therein for following downstream ignition andcontrolled temperature combustion within the temperaturesensor-transmitter monitored primary combustion zone 28 therein havingfurther admitted second controlled stream of working motive fluidcomposition gases supplied by conduit 22.

Within oxy-fuel fired combustion chamber assembly 26, the combined massflow of products of fuel combustion and streams of working motive fluidcomposition gases flows from the primary combustion zone 28 at acontrolled highly superheated presented example equilibrium temperatureof 2400 F into the downstream positioned tertiary blending zone 29wherein these said gases are blended with the controlled mass flow offore-described conduit 21 supplied first stream of working motive fluidcomposition gases.

The combined working motive fluid composition gases' mass flows enteringthe tertiary blending zone 29 within oxy-fuel fired combustion chamberassembly 26, Mixing together with primary combustion zone gases, thereinproduces a resultant selected equilibrium temperature and mass flow rateof superheated working motive fluid gases through conduit 30 into thehot gas expansion power turbine subassembly 3. Work is developed withinthe hot gas expansion power turbine subassembly 3, and the heat energyor enthalpy (Btu/lb) contained within the mass flow of expanded andexhausted working motive fluid gases is decreased and discharged intoconduit 37. Conduit 37 routes the hot gas expansion power turbinesubassembly exhaust gases through conduit end-branches 38 and 41 thatare respectively connected to WHRU exchanger 18 and waste heat recoverysteam generator (WHRSG) or waste heat recovery process fluid heater(WHRPF) exchanger 42. The proportional division of the total mass flowof the hot gas expansion power turbine subassembly 3 exhaust gascontained within conduit 37, between conduit end-branches 38 and 41, canbe flow-controlled or flow-proportioned respectively by damper valves 40and 44 contained within the WHRU exchanger 18 and WHRSG or WHRPFexchanger 42 respective outlet exhaust branch conduits 39 and 43. Thepredominant portion of conduit 37's total mass flow of exhaust gases isdivided and directed through WHRU exchanger 18 to satisfy the workingmotive fluid exhaust heat transfer requirements to the cited lowertemperature re-pressurized recycle gas flowing through exchanger 18.

In the case of waste heat transfer to a power cogeneration facility'ssupplied hot water/steam or process fluid circuit, a pressurized streamof a power cogeneration facility's steam condensate feed water (orprocess fluid) can be supplied from source 46 into conduit 47 that cantherein contain sensor-transmitter devices for both temperature and massflow, and having end-connectivity to the inlet header 48 of a secondWHRSG or WHRPF exchanger 49. In the case of stream generation, thesupplied stream of steam condensate can be changed from a liquid phaseto a liquid/vapor 2-phase state or slight superheated steam vapor statewithin exchanger 49, and exits from exchanger 49 through dischargeheader 50 into conduit 51 having end-connectivity to the inlet header 52of the first WHRSG exchanger 42. Within WHRSG exchanger 42, the steamcircuit stream can be highly superheated as desired to provide a powercogeneration facility produced steam superheat temperature that canrange from less than 900° F. to over 1200° F. for discharge from outletheader 53 into conduit 54 end-connected to point 55. For the alternativeaddition of the presented improved power cogeneration method's systemhaving increased or independent mass flow steam generation (as describedlater in FIG. 2), the hot gas expansion power turbine subassemblyexhaust gas conduit 37's end-branch conduit 41 can be supplied with aconnected side-branch conduct 56 whose end flange connection 57 can beclosed with a blind-flange cover in FIG. 1.

The presented power cogeneration method system's reduced temperatureexhaust gases exits from the WHRU exchanger 18 and theparallel-positioned WHRSG exchanger or WHRPF exchanger 42 (as earlierrecited) through their respective exhaust gas discharge branch conduits39 and 43, each branch conduit respectively therein can containcontrolled-flow damper valves 40 and 44. The reduced temperaturere-circulated exhaust gas flows from branch conduits 40 and 44 arecombined within re-circulated exhaust gas manifold 45 havingend-connectivity to a downstream-positioned second WHRSG exchanger orWHRPF exchanger 49. The power cogeneration method's re-circulatedexhaust gases are reduced in temperature within the second WHRSGexchanger or WHRPF exchanger 49 to a temperature that can be slightlyabove the dew point temperature of the re-circulated exhaust gas as itis discharged from the heat exchanger 49 into the exhaust gasdistribution manifold 10.

Within the presented invention's power cogeneration method includedpartially-open gaseous thermal fluid energy cycle and apparatus devices,the slightly superheated example turbine power engine unit'sre-circulated exhaust gas mass flow within exhaust gas distributionmanifold 10 remains at a constant flow rate during steady-state powercogeneration thermal energy conversion operations. During the recitedsteady-state operation, the recited method's generated excess ofslightly superheated re-circulated exhaust gas mass flow within manifold10, can be flow-directed from manifold 10 through side-branch conduit 58having downstream connectivity to atmosphere at vent point 61, and saidconduit may therein contain back pressure control valve 59 and flowcontrol valve 60. The terminal end of exhaust gas distribution manifold10 is provided with a closed blind flange connection 62 in FIG. 1.

FIG. 2 is a schematic flow diagram of the invention's improved powercogeneration method system as shown in FIG. 1, but therein havingspecifically added described alternative apparatus assembly devices thatcan include both an alternate separate motor or steam turbine drivenrecycle gas compressor and an oxy-fuel combustion chamber assembly thatis series-connected to a separate hot gas expansion turbine having anoutput power shaft. FIG. 2 further shows the power cogeneration method'sincluded partially-open gaseous thermal fluid energy cycle and apparatusdevices with the recited alternative addition of a separate oxy-fuelfired combustion burner assembly that performs the function of asupplementary hot exhaust gas generator that can increase the powercogeneration system's method production of either steam, hot water, orthe heating of process fluids.

Referring now more particularly to FIG. 2, the recited alternativeseparately driven recycle gas compressor 63 can comprise two or morerecycle gas compression stages, with a final gas compression stage thatcan incorporate an outward radially-directed discharge flow ofre-pressurized recycle gas. The recycle gas compressor 63 canalternately be directly driven by either an electric motor or a steamturbine type driver 64, or the said compressor indirectly-driven througheither gearbox or variable speed coupling assembly device 65. Therecited hot gas expansion power turbine assembly 67 can comprise one ormore power extraction turbine stages and an assembly output shaft thatcan be directly connected to electrical generator 7 wherein electricpower is produced and transmitted through conduit means 8 to a controlroom module 9. Control room module 9 therein contains the powercogeneration system's PLC control panel, and an electrical switchgearand motor control center which provides the means by which electricpower production can be controlled and distributed to the operatingfacility's electrical grid and/or to the utility electrical grid.Alternately (not shown), a gearbox or variable speed coupling can bepositioned between the power turbine assembly output shaft andalternative driven rotating pumps or compressors (not shown) in lieu ofgenerator 7.

Referring now more particularly to FIG. 2 and the flows of thermalfluids within the partially-open gaseous thermal fluid energy cyclecontained within the presented invention's power cogeneration methodcontaining alternative apparatus assembly devices. The slightlysuperheated exhaust recycle gas can flow from the exhaust gasdistribution manifold 10 with exiting flows through open end-connection62 that series-connects to manifold extension conduit 68 as furtherdescribed later. Manifold 10 side-branch connected exhaust recycle gasconduit means 11 is end-connected to the inlet of the exhaust gasrecycle gas compressor 63. The higher-pressure and higher-temperaturere-pressurized recycle exhaust gas (hereafter referred to as“re-pressurized recycle gas”) and related identical stream flows arethereafter the same as described as in FIG. 1 for its routing throughWHRU 18 and continuing to oxy-fuel fired combustion chamber assembly 26.The highly superheated working fluid gases emitted from the oxy-fuelcombustion chamber assembly 26 are routed through direct-connected gastransition assembly 66 with end connectivity to the inlet of the hot gasexpansion power turbine assembly 67.

Conduit 37 routes the hot gas expansion turbine assembly 67 exhaustgases through conduit end-branches 38 and 41 that are respectivelyconnected to WHRU exchanger 18 and WHRSG or WHRPF exchanger 42 andthereafter described associated conduit streams are as described forFIG. 1. For the alternative addition of the power cogeneration method'sdeveloped generation of additional thermal heat for transfer to steam,hot water, or process streams, fore-described conduit 68 can route aflow of slightly superheated exhaust recycle gas through preferredparallel end-branch conduits 69 and 70 that respectively can containflow proportioning or flow control provided isolation/damper valves 71and 72 and having end connectivity with one or more parallel-positioned73 and 74 speed-controlled motor-driven exhaust recycle gas blowers.Exhaust recycle gas blower 73 provides a required mass flow of exhaustrecycle gas at a slightly increased pressure into its discharge conduit75 having end-connectivity with the tertiary blending zone 82 containedwithin the downstream-positioned oxy-fuel fired combustion burnerassembly 79. Exhaust recycle gas blower 74 provides a required mass flowof exhaust recycle gas at a slightly increased pressure into itsdischarge conduit 76 having end-connectivity with the partial pre-mixsubassembly 80 contained within the downstream-positioned oxy-fuel firedcombustion burner assembly 79.

A controlled stream of low pressure predominant oxygen gas mixture issupplied from facility remote source 77 into conduit 84 that can containsensor-transmitter for oxygen %, temperature, pressure, mass flow, andoxygen flow control valve device 85, with said conduit 84 havingend-connectivity to either one or more preferred partial pre-mixsubassembly 80 contained within oxy-fuel fired combustion burnerassembly 79.

A low pressure stream of presented example methane fuel gas (oralternate acceptable liquid hydrocarbon fuel) is supplied from source 78into conduit 86 that can contain sensor-transmitter means fortemperature, pressure, mass flow, and fuel pressure/flow control valvemeans 87, with said conduit 86 having end-connectivity to either one ormore downstream-positioned preferred partial-premix subassembly 80contained within oxy-fuel fired combustion burner assembly 79.

Within the partial pre-mix subassembly 80, the said identified conduits76, 86, and 84 respectively supplied stream flows of exhaust recyclegas, fuel, and predominant oxygen gas mixture are therein blended forfollowing downstream ignition and controlled temperature combustionwithin the temperature sensor-transmitter monitored primary combustionzone 81 contained within oxy-fuel fired combustion burner assembly 79.

Within oxy-fuel fired combustion burner assembly 79, the predominantmass flow of combined products of fuel combustion and exhaust recycledgas flows from the primary combustion zone 81 (at a controlled highsuperheated presented example equilibrium temperature of 2400 F) intothe downstream tertiary blending zone 82 wherein these said compositiongases can be blended with the controlled mass flow of fore-describedconduit 75 supplied blower discharge stream of slightly re-pressurizedand low superheated exhaust recycle gases of identical molecular and Mol% gas composition.

The oxy-fuel fired combustion burner assembly 79 provides asupplementary mass flow of slightly re-pressurized and highlysuperheated recycle exhaust gas (which now can be referred to as“working motive fluid gas”) at controlled temperatures into conduit 83having end connectivity to conduit 56's flanged connection 57. Thesupplementary mass flow of slightly re-pressurized and highlysuperheated working motive fluid gas flow is routed through conduit 56into branch conduit 41 having connectivity to WHRSG exchanger or WHRPFprocess fluid exchanger 42, thereby enabling an increased mass flow ofsteam or hot water or process fluids (in conduits 47, 51, and 54 atgiven desired temperature operating conditions) to be transmittedthrough the WHRSG or WHRPF exchangers 49 and 42 from the invention'sincreased conduit 41 mass flows of highly superheated working motivefluid gas and conduit 45 recirculated exhaust gas mass flows of lessersuperheat gas temperature.

Within the presented invention's improved power cogeneration systemmethod, the slightly superheated partially-open cycle gaseous thermalfluid's recycle exhaust gas mass flow within conduit 11 remains at aconstant flow rate for steady-state example hot gas expansion turbineshaft horsepower output production. The excess slightly superheatedrecycle exhaust gas mass flow within manifold 10 that is not requiredfor steady-state power production, nor is required to maintain anexisting steady-state recycle exhaust gas mass flow rate within conduit68 for the oxy-fuel fired combustion burner assembly 79, isflow-directed from manifold 10 through side-branch conduit 58 that cancontain back pressure control valve 59 and flow control/isolation valve60 with downstream connectivity to atmosphere occurring at vent point61.

The numbers in Table 2 below are representative of: one example set offluid stream conditions in which the thermal fluid energy cyclecontained within the presented power cogeneration method system canoperate (the conduit streams are those identified by the numbers in FIG.1). The following assumptions were made: the recycle gas compressorefficiency and hot gas expansion turbine efficiency are both 84%; theoxy-fuel combustion burner assembly operating pressure is 60 psia; andthe methane fuel gas flow rate is 1 Mol/minute. TABLE 2 Conduit StreamStream Temperature Pressure Mass Flow Number Fluid Degree F. PSIAlbs./Min. 11 Recycle Exhaust 197 15 1879 12 Compressed Recycle 500 641879 22 WMF - Primary Zone 1350 63 686 21 WMF - Tertiary Zone 1350 631153 23 Cooled Compressed 280 63.5 40 Recycle 32 Methane Fuel 70 85 1635 Predominant O.sub.2 110 65 64 30 Combustion Working 1800 60 1959Motive Fluid 37 Turbine Engine Exhaust 1391 15.8 1959 45 WHRU & WHRSG530 15.4 1959 Exhaust 58 Cogen System Method 197 15.1 81 Vent Gas(WMF) = Working Motive Fluid

With the same example stream conditions and assumptions made for Table2, supra, Table 3 provides the thermodynamic values from which thetabulated compressor horsepowers and example power engine unit poweroutputs are derived. TABLE 3 Conduit Rotating Delta Horse- Stream**Equipment Stream Temperature Mass Flow Enthalpy Power Number Name FluidDegrees F. lbs./Min. Btu/Lb. (HP) 11 to 12 Exhaust Inlet  197 1879  98.94377 Recycle Discharge  500 Compressor 30 to 37 Hot Gas Inlet 1800 1959169.7 7837 Expander Discharge 1391 Turbine Net Shaft Horsepower Output3460 SHP**Note: (20,693,400 LHV Btu/Hr-Mol CH4) ÷ 3460 SHP = 5980 Btu/Hp-hr. fuelrate.*Note: Fuel Rate: (2545 Bt/Hp-hr. ÷ 5980 Btu/Hp-Hr. = 42.55% turbineengine thermal efficiency:**Note: Only the conduit stream numbers reference to both FIG. 1 andFIG. 2 drawings.

With the same conditions and assumptions made for Table 2, supra, Table4 contains six conduit streams (as noted) that appear in both FIG. 1 andFIG. 2, with the thermal heat transfers and mass flow rates pertainingonly to the FIG. 1 presented improved power cogeneration method systemand apparatus assemblies. TABLE 4 Conduit Heat Temperature Mass DeltaRecovered Stream Exchanger Stream Change Flow Enthalpy Heat Rate NumberName Fluid Degrees F. lbs./Min. Btu/Lb. Btu/Min. 37 to 45 18 + 42 TotalExhaust 1391 F. to 530 F. 1959 326 638,634 38 to 39 WHRU 18 Exhaust Gas1391 F. to 530 F. 1805.15 326 588,480 13/14-21/22 WHRU 18 ‘WMF’ Gas  500F. to 1350 F. 1839 320 588,480 41 to 43 WHRSG 42 Exhaust 1391 F. to 530F. 153.85 326  50,154* 45 to 10 WHRSG 49 Exhaust  530 F. to 197 F. 1959110  215,490* *Total Available Heat for Process Gas = (215,490 + 50,154)=   265,644 Btu/Min. or Steam Circuit *Total Available Heat for ProcessGas (265,644 Btu/Min. × 60) = 15,938,640 Btu/Hr. or Steam Circuit =Total 910 Btu/SCF LHV of 1 Mol/Min. 344,890 Btu/Min. = 20,693,400Btu/Hr. Methane Fuel Gas = Recovered Heat Rate from the Supplied =(15,938,640 Btu/Hr ÷ 20,693,400 77.02%. Fuel Gas Energy: LHV Btu/Hr-MolMethane Gas) = Total Improved Cogeneration Method = 42.5% Simple CycleTurbine 119.5%. System Thermal Efficiency: Power Engine Unit EnergyConversion Efficiency + 77.02% Recovered Heat Rate =

With the same conditions and assumptions made for Table 2 and 4 supra,Table 5 provides the thermal heat transfers and mass flow rates ascontained within the Alternative Cogeneration Method System of FIG. 2with added supplementary heat blended into the hot gas expansion turbineexhaust stream to increase the cogeneration method system's apparatusassemblies effective transfer of heat to steam or process heated fluidsby the example amount of 100%. TABLE 5 Conduit Heat Temperature MassDelta Recovered Stream Exchanger Stream Change Flow Enthalpy Heat RateNumber Name Gas Degrees F. lbs./Min. Btu/Lb. Btu/Min. 38 to 39 WHRU 18Turbine Exh. 1391 F. to 530 F. 1805 326 588,480  13/14-21/22 WHRU 18‘WMF’ Gas  500 F. to 1350 F. 1839 320 588,480  41/83-43 WHRSG 42 Exhaust1391 F. to 530 F.  763 326 248,738* 45 to 10 WHRSG 49 Exhaust  530 F. to197 F. 2568 110 282,480* 10 to 11 Recycle 1879 10 to 68 Recycle  197 F. 556 10 to 61 Exhaust Vent  138 35 + 84 95% Oxygen Mixture  120 F.  11232 + 86 Methane Fuel  70 F.  26 *Total Available Effective Energy =(248,738 + 282,480) = 531,218 31,873,080 Btu/Hr. Conversion to Heat forProcess Gas Btu/Min. = or Water/Steam Circuit: Turbine Power ApparatusEffective (2545) × (3460 SHP) =  8,805,700 Btu/Hr. Energy ConversionRate= Total Effective Energy 40,678,780 Btu/Hr. Conversion Rate= TotalSystem Fuel Energy (20,693,400 LHV Btu/Hr. for Turbine 33,687,002 LHVBtu/Hr. Consumption: Apparatus + 12,993,602 LHV Btu/Hr for SupplementaryOxy-Fuel Burner System) = Overall System Thermal (40,678,780 Btu/Hr.) ÷(33,687,002) = 120.75% Efficiency:

It should be understood that the forgoing description is onlyillustrative of the invention. Various altered method system andapparatus alternatives, fuels, and modifications to operating conditionscan be devised by those skilled in the art without departing from theinvention. Accordingly, the present invention is intended to embrace allsuch alternatives, modifications and variances which fall with the scopeof the following appended claims.

1. A power cogeneration partially-open oxy-fuel combustion cycle methodand system having recirculated gaseous thermal fluid and apparatusdevices for conversion of hydrocarbon fuel heat-value energy intomechanical energy power and transferable residual exhaust energy foruseful purposes, comprising: (a) a partially-open oxy-fuel combustioncycle method containing a continuously recirculated superheated gaseousthermal fluid; (b) one or more combustion chamber apparatus assembly orsubassembly device wherein temperature controlled oxy-fuel combustiontakes place; (c) one or more integral power engine unit apparatusassembly device wherein hydrocarbon fuel heat-value energy is convertedinto mechanical power energy and exhaust gas residual energy for usefulheating of other gaseous or liquid fluids; (d) an integral power unitapparatus device therein containing, but not limited to, a recycle gascompressor apparatus assembly or subassembly device, one or moreoxy-fuel combustion chamber assembly or subassembly device, and a hotgas expansion power extraction assembly or subassembly device; (d) twoor more alternative power engine unit apparatus assemblies orsubassembly devices collectively performing identical energy conversionstep functions as those performed within an integral power engine unitapparatus assembly; (e) one or more heat exchanger assembly devices,wherein
 1. a quantity of heat energy is extracted from one cited cyclerecirculated gaseous thermal fluid stream and transferred to either oneor more other cited cycle recirculated gaseous thermal fluid stream, 2.a quantity of heat energy is extracted from one cited cycle recirculatedgaseous thermal fluid stream and transferred to one or more othersupply/return fluid streams originating from outside the partially-opencycle and cogeneration system, and
 3. the heat exchanger assemblycontains one or more sections, each section therein having fluid heattransfer coils; (f) a valve apparatus device for controlling individualflow streams of fuel and a predominant oxygen mixture gas streamentering into the cited partially-open cycle and power cogenerationsystem from remote supply sources; (g) the power cogeneration systemtherein having control means for controlling an excess flow streamportion of the partially-open cycle's recirculated gaseous thermal fluidstream, the said excess controlled stream portion thereafter exhaustedfrom within the cited cycle and vented to atmosphere; (h) the powercogeneration system having conduit means therein providing for fluidflow communication between individual apparatus devices, and betweenapparatus devices within the system and other supply/return fluidstreams originating from outside the partially-open cycle's boundarylimits; (i) an alternative system addition of apparatus devices thereinindependently supplementing the production flow of oxy-fuel combustionexhaust gas flows within a conduit manifold having communication to oneor more exhaust waste heat recovery exchanger device; and (j) a powercogeneration system PLC control panel device having monitoring andcontrol communication with instrumentation and fluid flow controldevices mounted to and/or positioned within cited conduits and apparatusdevices, all said devices complying with industry and governmentalcodes/standards for safe operation and acceptable operating reliability.2. The partially-open oxy-fuel combustion cycle method's recirculatedsuperheated gaseous thermal fluid of claim 1 further comprising: (a) agaseous fluid whose molecular gas composition remains unchangedthroughout the cycle with a given employed fuel; (b) a gaseous fluidcontinuing throughout the cycle in a superheated temperature gaseousstate; (c) a gaseous fluid composed of highly predominate binary carbondioxide and binary water vapor exhaust gases; and (d) a gaseous fluid ofhighly superheated temperature having the thermal characteristic ofadsorbing or releasing approximately 40% more Btus of heat energy perpound of gas per degree Fahrenheit change in gas temperature, ascompared to conventional air/fuel combustion chamber exhaust gases. 3.The oxy-fuel combustion cycle method and apparatus devices of claim 1further comprising: (a) one or more oxy-fuel combustion chamber deviceswherein temperature controlled combustion takes place, said combustionand generated heat of combustion dispersal being highly accelerated,thereby achieving an extremely rapid preset uniform equilibriumtemperature of gases within the cited oxy-fuel combustion chamber; (b)one or more oxy-fuel combustion chamber devices wherein temperaturecontrolled combustion takes place, said combustion comprising a primarycombustion flame zone wherein hydrocarbon fuel and oxygen chemicalreactions produce extraordinary high superheated water vapor and carbondioxide as products of said combustion; (c) one or more oxy-fuelcombustion chamber devices wherein a mass of generated extraordinaryhigh superheated water vapor and carbon dioxide combustion gaseousproducts radiantly emit their individual gas heat energy to other likegases therein adsorbing the cited radiated heat energy at the speed oflight velocity of 186,000 miles per second; (d) an ultra-low level ofresultant generated oxy-fuel combustion exhaust emissions of nitrogenoxide and carbon monoxide gases achieved from a control of presetcombustion chamber primary zone equilibrium temperature, saidtemperature being below that in which the cited exhaust emissions areproduced from disassociation chemical reactions; (e) the citedpartially-open cycle containing a recirculated superheated gaseousthermal fluid, said gaseous fluid then re-pressurized or compressed by acited recycle compressor and thereafter increased in superheattemperature to establish a cycle gas stream then referred to as a“working motive fluid” gas stream; (f) the cycle's working motive fluidgas having mass flows, gas thermal characteristics, and highlysuperheated temperatures for the highly efficient conversion of thermalheat energy into mechanical power, and useful transfer of residualthermal energy to other fluid streams; (g) an oxy-fuel combustionchamber having partial premix assembly means of co-mingling and/orhomogeneously blending introduced controlled flow streams of workingmotive fluid gas, fuel, and predominant oxygen gas mixture for aresulting controlled ignition/combustion temperature of said fuel; (h)an introduced individual controlled fluid stream of fuel, and ofseparate predominant oxygen mixture stream, into the partially-opencycle through conduit means originating from remote supply sourcesexterior to the recited cycle boundary limits; (i) a mass mixture ofpressurized working motive fluid gases introduced into the citedoxy-fuel combustion chamber and combined with fuel combustion productgases, the combined gases thereafter expanded through a apparatus devicemeans to convert the said gases' thermal energy into mechanical powerenergy; and (j) a steady-state partial-open thermal fluid energy cyclemethod wherein controlled conduit mass flows of excess recirculatedexhaust gases, said gases exhaust-vented from the cited cycle toatmosphere, are in mass flow equilibrium with the combined mass flows offuel and predominant oxygen mixture entering into cited cycle.
 4. Thecycle's recirculated superheated gaseous thermal fluid method of claim 1further comprising: (a) a method gaseous molecular mixture composed ofhighly predominate binary carbon dioxide and binary water vapor gaseshaving a carbon dioxide Mol % to water vapor Mol % ratio therein beingidentical to the carbon dioxide Mol % to water vapor Mol % ratio ofthese products of combustion as generated by the combustion of a givenhydrocarbon fuel; and (b) a method gaseous molecular mixturepredominately consisting of carbon dioxide and water vapor, withrespectively lesser descending Mol percents of argon, excess combustionoxygen, nitrogen, and rare atmospheric gases completing the totalmolecular composition of the thermal fluid's gaseous molecularcomposition.
 5. The integral power engine unit apparatus assembly deviceof claim 1 further comprising: (a) An exhaust gas recycle compressorassembly or subassembly device connected by shaft means to a laterdescribed hot gas expansion power extraction assembly or subassemblydevice; (b) One or more oxy-fuel combustion chamber/combustor assemblyor subassembly device; (c) A hot gas expansion power extraction assemblyor subassembly device, therein converting an oxy-fuel combustion chamberassembly's discharged working motive fluid with gaseous thermal andpressure expansion energy into mechanical shaft output energy; and (d)an emitted flow of reduced temperature working motive fluid exhaustgases, therein discharged into an exhaust conduit manifold connected toa later described downstream-positioned waste heat recovery exchangermeans.
 6. The two or more alternative power unit apparatus assemblies ofclaim 1 further comprising: (a) an integral motor or steam turbinedriven exhaust gas recycle compressor apparatus assembly, thereinreplacing the cycle function performed by the exhaust gas recyclecompressor assembly or subassembly device within the fore-cited integralpower engine unit apparatus assembly device; and (b) an integralapparatus assembly containing an oxy-fuel combustion chamber subassemblyconnected to a hot gas expansion power extraction assembly orsubassembly.
 7. The heat exchanger assembly devices of claim 1 furthercomprising: (a) a power engine unit exhaust waste heat recovery unit(WHRU) exchanger assembly conduit-positioned downstream of a powerengine unit for transfer of power engine unit exhaust gas residual heatenergy to fluid coils contained within two parallel exchanger sectionscontained within the WHRU exchanger assembly; (b) a power engine unit‘first’ exhaust waste heat recovery stream generator (WHRSG) exchangerassembly, or waste heat recovery process fluid (WHRPF) exchangerassembly, hereafter referred to as the WHRSG/WHRPF exchanger assemblypositioned in parallel with the WHRU exchanger assembly and havingconduit communication to a power engine unit's exhaust manifold; (c) apower engine unit ‘first’ WHRSG/WHRPF exchanger assembly having conduitcommunication with the power engine unit exhaust manifold for thetransfer of exhaust gas residual heat energy to fluid coils containedwithin the WHRSG/WHRPF exchanger assembly; (d) a power engine unit‘second’ exhaust gas WHRSG/WHRPF heat exchanger assembly comprising
 1. aheat exchanger assembly having a upstream common manifold conduitcommunication with the parallel connected WHRU and ‘first’ WHRSG/WHRPFexchanger assemblies,
 2. a heat exchanger assembly discharging slightlysuperheated recirculated exhaust gas into a downstream exhaust gasdistribution manifold means, and
 3. a heat exchanger assemblytransferring exhaust gas residual heat energy to hot water/steam coilsor process fluid coils contained within the exchanger assembly; (e) anair-cooled exchanger through which a small controlled stream flowportion of recited primary recycle gases is cooled and conduit-connectedto one or more fore-cited oxy-fuel combustion chamber assembly.
 8. Oneor more combustion chamber apparatus assembly or subassembly device ofclaim 1 further comprising: (a) a partial premix subassembly thereinreceiving controlled communicating flow streams of
 1. a gaseous orliquid hydrocarbon fuel from a connected remote source,
 2. a gaseousmixture of predominant oxygen gases from a connected remote source, and3. a low gas flow stream of primary re-pressurized and slightlysuperheated recycle gas from a connected fore-cited air-cooled heatexchanger; (b) an internal primary combustion zone within each oxy-fuelcombustion chamber assembly therein receiving a communicating secondflow stream of working motive fluid from the fore-cited WHRU heatexchanger; (c) an internal tertiary blending zone within each oxy-fuelcombustion chamber assembly, therein receiving a communicating firstflow stream of working motive fluid from the fore-cited WHRU heatexchanger.
 9. An alternative cycle method and apparatus devices forindependently supplementing the production flow of oxy-fuel combustionexhaust flows of claim 1 further comprising: (a) one or more exhaustrecycle gas blower and common oxy-fuel fired combustion burner assemblybeing parallel gas flow-positioned within the cycle to the power engineunit apparatus; (b) an inlet to each gas blower being conduit-connectedwith a supply of ‘exhaust recycle gas’ withdrawn from the cycle system'sexhaust gas distribution manifold; (c) one or more gas blowers, where inthe case of two parallel-positioned gas blowers, individual blowercontrolled gas discharge streams have conduit-connectivity respectivelywith a partial premix subassembly and a tertiary blending zone within aoxy-fuel fired combustion burner assembly; (d) a controlled conduit flowstream of supplied predominant oxygen mixture gas and a controlledconduit flow stream of supplied fuel, wherein each said stream isconduit end—connected with the oxy-fuel fired combustion burnerassembly's partial premix subassembly; (e) the oxy-fuel fired combustionburner assembly having an exhaust gas flow conduit connectivity to, andco-mingled with, the power engine unit exhaust gases contained within anexhaust conduit manifold having connectivity to the downstreampositioned fore-cited WHRU and WHRSG/WHRPF heat exchanger assemblydevices.
 10. a hot gas expansion power extraction assembly orsubassembly device means of claim 5, wherein a compressed and highlysuperheated working motive fluid is expanded to a lesser pressure andtemperature thereby creating mechanical energy, the hot gas expansionpower extraction device configured as: (a) a conventional rotating hotgas power turbine assembly or subassembly device having two or morepower turbine wheel expander stages; (b) a conventional rotating hot gaspower turbine assembly or subassembly device having one or morefirst-positioned power turbine wheel expander stages with shaftdirect-connected to a recycle gas compressor assembly; (c) aconventional rotating hot gas power turbine assembly or subassemblydevice having one or more last-positioned power turbine wheel expanderstages with direct-connected output mechanical drive shaft; and (d) aless conventional rotating hot gas power turbine apparatus assembly orsubassembly device having one or more power turbine wheel expanderstages with direct-connected output mechanical drive shaft.
 11. one ormore integral power engine unit apparatus assembly device of claim 1having a configuration comprising but not limited to either one of: (a)a presented and described modified rotating gas turbine apparatusassembly; (b) a presented and alternative described two or more combinedmodified conventional rotating apparatus assemblies in combination witha oxy-fuel combustion chamber assembly device; (c) a modifiedreciprocating type engine apparatus assembly device having two or moresubassembly devices therein including one or more reciprocating pistonsubassembly devices having articulating communication means with arotating mechanical power output crankshaft means.
 12. A conduit meansof claim 1 providing for fluid flow communication between individualapparatus devices within the cited cycle, and further providing forfluid flow communication between apparatus devices within the citedcycle and cycle-remote fluid connection points of fluid supply and/orfluid return, said conduit means further comprising: (a) Three or moreselected conduit means therein containing fluid flow control valves orpressure control valves, and sensor/transmitter instrumentation deviceshaving electronic signal communication with a power cogeneration systemPLC type control panel; (b) All conduits with interior flows of cyclegaseous thermal fluid therein having exterior conduit-connectedinsulation means for purposes of minimizing heat losses from the recitedpartially-open cycle, and for purposes of facility personnel safety; and(c) sensor/transmitter instrumentation devices having electronic signalcommunication with a power cogeneration system PLC type control panel.13. The recited sensor/transmitter instrumentation devices of claim 12further comprising but not limited to: (a) the cycle gaseous thermalfluid streams' temperature and pressure sensing devices as required forcycle control purposes, (b) a fuel supply stream's pressure andtemperature sensing device, (c) an oxy-fuel combustion chamberassembly's primary combustion zone and tertiary zone dischargetemperature sensing devices, (d) the cycle gaseous thermal fluidstreams' mass flow calculating devices as required for cycle andcogeneration method control purposes, (e) a cycle gaseous thermalfluid's recirculated exhaust stream oxygen content sensing/calculatingdevice, and (f) a cycle oxygen supply source stream's pure oxygencontent sensing/calculating device.
 14. A power cogeneration system PLCtype control panel of claim 12 further comprising but not limited to:(a) the means of receiving electronic input data signals fromsensor/transmitter devices, said signals having relevance to monitoringfor safe operating conditions and the control of conduit fluid flows asrequired to meet cycle produced power output demands and demands fortransferred waste heat to other cycle-exterior fluid streams; (b) thealternative means of receiving electronic input data signals from amanufacturer's standard power engine unit PLC control panel, the saidinput data signals being power cogeneration PLC control panel integratedas necessary for the control and safe operation of the oxy-fuel cycleand complete power cogeneration system; (c) the cited power cogenerationPLC control panel means of transmitting PLC computed electronic outputdata signals to the appropriate fluid flow control valves in response tocited input signals, a response output signal change including but notlimited to
 1. a change in output signal to the valve that control theflow of predominant oxygen mixture into the cited cycle, following asignal change from the oxygen sensor positioned in the cycle'srecirculated exhaust manifold,
 2. a change in output signal to the valvethat controls the flow of fuel into the cycle, following a change insignal from the temperature sensor in the oxy-fuel combustion chambers'primary zone, and
 3. a change in separate output signals to the separatevalves that control the flows of fuel and predominant oxygen mixtureinto the cited cycle, and a change in signal to a recycle gascompressor's output flow control means, following a change of afacility's input signal corresponding to a change in facility powerdemand on the power cogeneration system.